|Publication number||US7629067 B2|
|Application number||US 11/750,833|
|Publication date||8 Dec 2009|
|Filing date||18 May 2007|
|Priority date||22 May 2006|
|Also published as||CA2684318A1, EP2038955A2, EP2038955A4, US8438907, US20080003471, US20100081023, WO2007136849A2, WO2007136849A3|
|Publication number||11750833, 750833, US 7629067 B2, US 7629067B2, US-B2-7629067, US7629067 B2, US7629067B2|
|Inventors||Clint A. Beliveau, Scott C. Elliot, Vernon Wade Popham|
|Original Assignee||Idatech, Llc|
|Export Citation||BiBTeX, EndNote, RefMan|
|Patent Citations (108), Non-Patent Citations (9), Referenced by (3), Classifications (19), Legal Events (7)|
|External Links: USPTO, USPTO Assignment, Espacenet|
The present disclosure claims priority under 35 U.S.C. § 119(e) to U.S. Provisional Patent Application Ser. No. 60/802,715, which was filed on May 22, 2006 and the entire disclosure of which is herein incorporated by reference for all purposes.
The present disclosure relates generally to liquid leak detection systems, and to fuel cell systems and hydrogen-producing fuel processing systems that include a liquid leak detection system.
Hydrogen-producing fuel processing systems are adapted to produce, via chemical reaction, a product stream containing hydrogen gas as a majority component from at least one feedstock. Many such fuel processing systems are adapted to produce hydrogen gas from at least one liquid carbon-containing feedstock. In some fuel processing systems, more than one carbon-containing feedstock is utilized. In some fuel processing systems, water is also utilized as a feedstock. In some fuel processing systems, the one or more feedstocks are vaporized prior to being chemically reacted, or reformed, to produce the hydrogen-rich product stream.
The liquid carbon-containing feedstock is often an alcohol or hydrocarbon and is generally flammable. The liquid carbon-containing feedstock, either alone or in combination with water, is typically pumped or otherwise transported from a fuel supply or fuel source to regions of the fuel processing system where it is consumed. In some embodiments, the feedstock is consumed as a fuel for a burner or other heating assembly in addition to being used as a reactant for the production of hydrogen gas. Typically liquid (or other fluid) transport tubing provides conduits through which the feedstock flows. It is possible for leaks to occasionally occur, such as from the tubing, from couplings for the tubing, from couplings between other components of the fuel processing system, etc. Timely detection of such a leak, should it occur, is therefore desirable, especially in the context of flammable liquid carbon-containing feedstocks.
A fuel processing system containing a liquid leak detection system according to the present disclosure is shown in
The fuel processing assembly is adapted to receive one or more feed streams 16 from a feedstock delivery system 22. Feedstock delivery system 22 is adapted to draw or otherwise receive a liquid carbon-containing feedstock from a supply, or source, that contains the liquid carbon-containing feedstock and to deliver a feed stream 16 containing the feedstock for use in at least the hydrogen-producing region of the fuel processing assembly. In some embodiments, the feed stream and/or liquid carbon-containing feedstock may also be consumed as a fuel for a heating assembly that combusts the feedstock in the presence of air to heat at least the hydrogen-producing region of the fuel processing assembly. Feedstock delivery system 22 may utilize any suitable delivery mechanism, such as a positive displacement or other suitable pump or mechanism for propelling liquid fluid streams. When one or more pumps are used, the number, type and capacity of the pumps may vary, such as with respect to the desired flow rate of liquid to be pumped thereby, the desired pressure to be provided to the liquid, the composition of the liquid, whether or not the flow rate is intended to be selectively varied, etc. Illustrative, non-exclusive examples of pumps that may be used include diaphragm pumps, metering pumps, gear pumps, and the like. In some embodiments, the feed stream may be received from a pressurized source, and in some such embodiments, an additional pump may not be required downstream from the source. Illustrative, non-exclusive examples of suitable feedstock delivery systems are disclosed in U.S. Published Patent Application No. 2007/0062116, the complete disclosure of which is hereby incorporated by reference for all purposes.
Examples of suitable mechanisms for producing hydrogen gas from feed stream(s) 16 delivered by feedstock delivery system 22 include steam reforming and autothermal reforming, in which reforming catalysts are used to produce hydrogen gas from a feed stream 16 containing a liquid carbon-containing feedstock 18 and water 17. Other suitable mechanisms for producing hydrogen gas include pyrolysis and catalytic partial oxidation of a carbon-containing feedstock, in which case the feed stream does not (or does not need to) contain water. Illustrative, non-exclusive examples of suitable carbon-containing feedstocks 18 include at least one hydrocarbon or alcohol. Illustrative, non-exclusive examples of suitable liquid hydrocarbons include diesel, kerosene, gasoline and the like. Illustrative, non-exclusive examples of suitable alcohols include methanol, ethanol, and polyols, such as ethylene glycol and propylene glycol.
While a single feed stream 16 is shown in
When the liquid carbon-containing feedstock is miscible with (liquid) water, the feedstock is typically, but is not required to be, delivered with the water component of feed stream 16, such as shown in
Steam reforming is one non-exclusive example of a hydrogen-producing mechanism that may be employed in hydrogen-producing region 19 in which feed stream 16 comprises water and a carbon-containing feedstock. In a steam reforming process, hydrogen-producing region 19 contains a suitable steam reforming catalyst 23, as indicated in dashed lines in
Another illustrative, non-exclusive example of a suitable hydrogen-producing reaction that may be utilized in hydrogen-producing region 19 is autothermal reforming, in which a suitable autothermal reforming catalyst is used to produce hydrogen gas from water and a carbon-containing feedstock in the presence of air. When autothermal reforming is used, the fuel processor further includes an air delivery assembly 67 that is adapted to deliver an air stream to the hydrogen-producing region, as indicated in dashed lines in
As an illustrative example of temperatures that may be achieved and/or maintained in hydrogen-producing region 19 through the use of a heating assembly 60, hydrogen-producing steam reformers typically operate at temperatures in the range of 200° C. and 900° C. Temperatures outside of this range are within the scope of the disclosure. Steam and autothermal reformers also tend to operate at elevated pressures, such as pressures in the range of 50 and 1000 psi, although pressures outside of this range may be used and are within the scope of the present disclosure. When the carbon-containing feedstock is methanol, the steam reforming reaction will typically operate in a temperature range of approximately 200-500° C. Illustrative subsets of this range include 350-450° C., 375-425° C., and 375-400° C. When the carbon-containing feedstock is a hydrocarbon, ethanol, or another alcohol, a temperature range of approximately 400-900° C. will typically be used for the steam reforming reaction. Illustrative subsets of this range include 750-850° C., 725-825° C., 650-750° C., 700-800° C., 700-900° C., 500-800° C., 400-600° C., and 600-800° C. It is within the scope of the present disclosure for the hydrogen-producing region to include two or more zones, or portions, each of which may be operated at the same or at different temperatures. For example, when the hydrogen-production fluid includes a hydrocarbon, in some embodiments it may be desirable to include two different hydrogen-producing portions, with one operating at a lower temperature than the other to provide a pre-reforming region. In such an embodiment, the fuel processing system may alternatively be described as including two or more hydrogen-producing regions and/or as including two of more hydrogen-producing regions that are connected in series, with the output stream from the first region forming at least a portion of the feed stream for the second hydrogen-producing region. Illustrative, non-exclusive examples of suitable heating assemblies for use with fuel processing assemblies according to the present disclosure are disclosed in U.S. Published Patent Application Ser. Nos. 2003/0192251, 2003/0223926, and 2006/0272212, the complete disclosures of which are hereby incorporated by reference for all purposes.
As also shown in
It is within the scope of the disclosure that combustion stream 66 may additionally or alternatively be used to heat other portions of the fuel processing system and/or fuel cell system with which heating assembly 60 is used. It is also within the scope of the present disclosure that other configurations and types of heating assemblies 60 may be utilized. As an illustrative further example, a heating assembly 60 may be an electrically powered heating assembly that is adapted to heat at least the hydrogen-producing region of the fuel processing assembly by generating heat using at least one heating element, such as a resistive heating element. Therefore, it is not required that heating assembly 60 receive and combust a combustible fuel stream to heat hydrogen-producing region 19 to a suitable hydrogen-producing temperature.
Fuel processing systems 10 according to the present disclosure also include a liquid leak detection system 160 that is adapted to detect liquid that leaks from components of the fuel processing system. As illustrative, non-exclusive examples, the liquid leak detection system may be positioned or otherwise configured to detect liquid leaks from one or more of feedstock delivery system 22, heating assembly 60, and various fluid delivery conduits through which the liquid feedstocks and/or fuels travel within the fuel processing system. An illustrative, non-exclusive example of these fluid delivery conduits, or fluid conduits, is one or more feed conduits that extend between the feedstock delivery system and the hydrogen-producing assembly and/or hydrogen-producing region thereof, and through which the feed stream containing at least a carbon-containing feedstock flows during use of the fuel processing system to produce hydrogen gas from the feed stream. As another illustrative, non-exclusive example, these fluid conduits may include at least one fuel conduit that extends between a fuel source, such as from feedstock delivery system, and a heating assembly that is adapted to receive and combust a liquid fuel, and through which the liquid fuel flows to the heating assembly when the heating assembly is combusting liquid fuel to produce a heated exhaust stream. In some embodiments, the liquid leak detection system also may be referred to as a liquid spill detection system.
Liquid leak detection system 160 is adapted to detect liquid that leaks or otherwise is emitted to, or present in, regions of the fuel processing system (including any associated housing, shell, support surface, or other enclosure) where the liquid should not be present during proper operation of the fuel processing system. In other words, the liquid leak detection system is configured to detect liquid in or adjacent regions of the fuel processing system where liquid is not present during proper, or desired, operation of the fuel processing system. In some embodiments, the liquid leak detection system may be adapted to detect any liquid. In some embodiments, the liquid leak detection system may be configured to detect certain liquids and/or liquids with certain properties. In such an embodiment, the liquid leak detection system may accordingly be configured to detect certain liquids while not detecting (and/or being actuated by) other liquids.
Upon detection of liquid (or in some embodiments, a liquid with a predetermined property), the liquid leak detection system, and/or an associated control system in communication with the detection system, may be configured to at least one of stop or otherwise interrupt the operation of the fuel processing system, generate an alert signal, and/or transition (and/or cause the transitioning of) the fuel processing system to a different operating state. Interrupting the operation of the fuel processing system may include one or more of such illustrative, non-exclusive steps of stopping the delivery of one or more feedstocks to the hydrogen-producing region, stopping the delivery of one or all feed streams to the hydrogen-producing region, stopping the operation of the feedstock delivery system, stopping the delivery of fuel and/or power to the heating assembly, shutting down the fuel processing system, etc. Generating an alert signal may include generating at least one audible, visible, and/or electronic alert signal. For example, a siren or indicator light may be used as audible and visible signals, while an electronic alert signal may be sent, for example, to a remote location to indicate, or otherwise provide notification of, the detected leak. Transitioning the fuel processing system to a different operating state may include transitioning to an idle or faulted operating state in which no, or only minimal, hydrogen gas is produced by the fuel processing assembly. In an idle operating state, the fuel processor may be maintained at suitable temperatures and pressures for producing hydrogen gas, whereas in a faulted operating state the fuel processor may be cooled and/or depressurized to a temperature and/or pressure that is less than minimum hydrogen-producing temperatures and/or pressures. Illustrative examples of suitable operating states, and related fuel processing systems and control systems, are disclosed in U.S. Pat. Nos. 6,495,277 and 6,383,670, the complete disclosures of which are hereby incorporated by reference for all purposes. The above illustrative examples of responses to the detection of a liquid leak by detection system 160 are intended to provide illustrative, non-exclusive examples. It is within the scope of the present disclosure that other responses may be utilized, either in place of or in addition to one or more of the above-presented examples.
If the detected signal has a predetermined relationship to the threshold value that is indicative of a liquid leak, such as with the detected signal being equal to, greater than, at least as great as, less than, or not greater than, the threshold value, then the detection system may cause a predetermined response, such as one or more of the illustrative responses discussed above. If a detected signal does not have such a predetermined relationship to the threshold value, thereby indicating either no detected liquid leak or a detected leak that is below the predetermined threshold level or quantity, then the detection system may simply continue monitoring for a detected signal that is indicative of a (sufficient) liquid leak. In this latter example, the signal detector may be configured to monitor any signal detected thereby without requiring a corresponding change in the signal emitted by the signal emitter. For the purpose of illustration, the following discussion will refer to monitoring the detected signal to see if the detected signal is at least as great as the threshold level. However, and as discussed above, it is within the scope of the present disclosure that the detection system may be configured to monitor for other relationships between the detected signal and one or more threshold values.
Liquid leak detection system 160 may be configured to monitor and/or compare any suitable relationship between the emitted signal, the detected signal, and/or a threshold value. As an illustrative, non-exclusive example, the liquid leak detection system may be configured to generate, induce, or otherwise impart an electrical signal to, or on, signal emitter 166 and to monitor the amount, or level, of that signal that is detected by signal detector 168. In such an embodiment, the signal emitter and signal detector are placed in proximity to each other, such as in a spaced-apart relationship. Then, the level of the signal detected by signal detector 168 may be monitored and compared to a threshold value.
As an illustrative, non-exclusive example, an AC signal (2 KHz, square wave) was imparted to the signal emitter, and the level (i.e., the percentage) of signal detected by signal detector 168 was monitored and compared (such as with suitable op-amp circuitry) to a threshold value to determine if a liquid leak was detected. The signal detector was spaced-apart from the signal emitter, such as by being separated by non-conductive material. Without leaked liquid providing a conductive path between the signal detector and the signal emitter, the signal detector does not detect a signal that is at least as great as the threshold value. However, leaked liquid that contacts and extends between the signal emitter and the signal detector may increase the degree to which the signal detector absorbs, or receives, the emitted signal.
The threshold value may be selected so that the signal detector does not detect a sufficient level of the signal emitted by the signal emitter when liquid is not bridging or otherwise contacting the signal emitter and the signal detector. The distance between the signal emitter and the signal detector may affect the degree to which the signal imparted to the signal emitter is detected by the signal detector. Similarly, any material between or connecting the signal emitter and signal detector may affect the degree to which the signal detector detects the signal from the signal emitter. Therefore, the particular materials, signals, signal properties, detector properties, liquids to be detected, desired sensitivity, etc. may be factors that are considered when selecting a threshold value. The threshold value may be stored by a memory portion of a controller associated with the detection system, computed based on the emitted signal, etc. Regardless of whether and/or where the threshold value is stored, the threshold value may be a fixed value, may have a fixed relationship to an operating parameter of the fuel processing system (or measured by the controller), and/or may vary such as with respect to operator preferences and/or one or more operating parameters of the fuel processing system.
In some embodiments, the conductivity of the leaked liquid may affect the degree to which the emitted signal is detected by the signal detector. However, conductivity tends to vary with temperature. Therefore, and while not required to all embodiments, it is within the scope of the present disclosure that the threshold value may vary with temperature. As an illustrative example, and as schematically illustrated in
The above-discussed monitoring and comparison (and any resultant output signal or command signal) may be performed by a suitable controller, logic circuit, processor, comparator, etc. As discussed, if the fuel processing system includes a control system with a microprocessor or other suitable controller, this controller may perform the monitoring and comparing, although this is not required.
The signal emitter and signal detector may be implemented with any suitable structure and in any suitable manner. It is within the scope of the present disclosure that the signal emitters and signal detectors discussed and/or illustrated herein may themselves perform the discussed signal generation, signal emitting, signal detecting, signal comparing, and/or signal monitoring operations. However, it is also within the scope of the present disclosure that signal emitter 166 and/or signal detector 168 may be in communication with at least one controller, processor, or other component or device that partially or completely performs one or more of these operations.
As an illustrative, non-exclusive example, the signal emitter and signal detector may be implemented as electrical traces that are etched or otherwise implemented in a printed, or other, circuit board. As another illustrative, non-exclusive example, the signal emitter and signal detector may be positioned in or on a support material, optionally with insulating material separating the signal emitter and the signal detector while still providing a contact region in which leaked liquid may contact the signal emitter and/or the signal detector. When the signal detector and/or the signal emitter are positioned on, or in, a support material, the support material may have any suitable construction and shape.
In some embodiments, it may be desirable for the support material to have a planar configuration, while in others it may be desirable for the support material to have a non-planar configuration. An illustrative, non-exclusive example of a non-planar configuration is a configuration in which the support material has a concave or bowl-shaped configuration that urges leaked liquid to a collection, or pooling, region. As another illustrative example, the support material may be shaped to define a discrete (typically low) number of spaced-apart collection, or pooling, regions. As still another illustrative example, the support material may be shaped to conform to the shape of the base, or lower region of a housing that contains at least portions of the fuel processing assembly and/or to conform to the shape of portions of the fuel processing assembly that the detection system is designed to be positioned beneath to detect liquid leaks therefrom. In some embodiments, a planar configuration may be desirable because it does not urge leaked liquid to a particular region of the material, while in other embodiments, a shaped non-planar configuration may be desirable.
As a design consideration, some fuel processing assemblies are designed to remain stationary and level when in use. However, other fuel processing assemblies, such as assemblies that are designed for use in vehicles and/or in marine applications, may be expected to be periodically inclined or repositioned during use. This expected motion, or lack of motion, may impact the selected configuration for the signal detector of the liquid leak detection system.
As discussed, at least one potential response to liquid leak detection system 160 detecting a liquid leak is for the operation of the fuel processing system to be stopped or otherwise interrupted. As also discussed, the fuel processing system may utilize a variety of liquids, such as water and at least one carbon-containing feedstock. It follows then that some liquid (i.e., water) may not be as hazardous or indicative of a potential system failure as others (i.e., carbon-containing feedstock). Similarly, it is possible that water may be introduced into the fuel processing system (and/or upon the detection system's signal detector) without this water being the result of a leak or malfunction of the fuel processing system. For example, liquid water may form from condensation due to temperature changes within the fuel processing system, due to humidity in the location where the fuel processing system is being operated, etc.
It is also possible that solids may be deposited on the signal detector, the signal emitter, and/or material separating these components. Illustrative, non-exclusive examples of solids that may be deposited include salts (such as from marine environments), particulate carried by the air in the environment in which the fuel processing assembly is operated, etc. Some of these deposits may be conductive or otherwise affect the detected signal, such as to cause the signal detector to detect a sufficient signal that is indicative of a liquid leak. Accordingly, it is possible that liquid leak detection system 160 may detect a liquid leak at times when liquid has not actually leaked from the fuel processing assembly. Such a false positive, or false leak, if detected, may be acceptable in view of the potential value of detection system 160 being present to also detect an actual liquid leak.
In some embodiments, liquid leak detection system 160 may include a cover, or barrier, that is positioned to restrict some liquids and solids from contacting the signal emitter and/or the signal detector. For example, the cover may be positioned on or above any of the liquid detectors 162 described, illustrated, and/or incorporated herein. When the liquid detector includes a signal emitter and a signal detector, the cover may be positioned above these components of the liquid leak detection system. In
In some embodiments, cover 180 may be formed from a liquid-permeable material and/or a liquid-absorbent material 184. In such an embodiment, the cover may be described as being a solid, or particulate, barrier. When the material is an absorbent material, it may promote the distribution of any leaked liquid to the signal detector and/or signal emitter.
In some embodiments, the cover may be formed from or include a material that repels, or is not permeable to, one or more selected liquids. As an illustrative, non-exclusive example, cover 180 may include (and/or be coated with) a hydrophobic material 186 or a material that promotes beading of water upon the surface thereof. When such a material is utilized, the material may also be selected to be permeable to one or more liquid carbon-containing feedstocks that are utilized by the fuel processing assembly. As discussed, illustrative liquid carbon-containing feedstocks include methanol or other alcohols, gasoline, diesel, kerosene, and the like. Utilizing such a material for, or in, cover 180 may enable the cover to be configured or otherwise constructed permit the carbon-containing feedstock to pass through, or even be drawn through, the cover to the signal emitter and/or signal detector while retarding or impairing water from passing through the cover.
As an illustrative, non-exclusive example, consider a fuel processing assembly that is adapted to produce hydrogen gas from a liquid feed stream containing methanol and water. The methanol (or other carbon-containing feedstock portion of the feed stream), if leaked, may pass through the cover to actuate the liquid leak detection system even though the water may not (or may not appreciably) pass through the cover. On the other hand, if water condenses or otherwise is introduced into the fuel processing assembly and contacts cover 180, the water may be prevented (at least within the water-repelling capacity of the cover) from passing through the cover to actuate the detection system.
In some embodiments, the cover may include conductive particulate or conductive components 188 that are adapted to be extracted or otherwise removed from the cover with liquid that passes through the cover. The inclusion of these components 188 in the cover may increase the ability of leaked liquid that passes through the cover to actuate the detection system. For example, components 188 may increase the conductivity of the leaked liquid or otherwise increase the signal to noise ratio of the emitted signal.
Cover 180 may be formed in one or more layers and may be positioned on or spaced above the signal detector and the signal emitter. In some embodiments, cover 180 may include two or more layers of the same or different materials. In some embodiments, cover 180 (when present) may be secured to the signal detector and the signal emitter. The thickness and other materials of construction of the cover may be selectively varied, such as to adjust the sensitivity of the liquid leak detection system. Cover 180, when present, should be selected to be suitable for use in the operating environment, including the operating temperature, where the liquid leak detection system is utilized. In experiments, ceramic paper and ceramic felt have proven effective. A particular, non-exclusive example is Lytherm 550-L ceramic paper, although others may be used.
In some embodiments of liquid leak detection systems that include a cover, it may be desirable for the cover to have a uniform thickness. However, in other embodiments, a variable thickness cover may be used, such as to include thinner covers in regions where it is desirable for the detection system to be actuated (i.e., detect a leak) when less liquid has leaked or otherwise been emitted than in other areas where the cover is relatively thicker. Correspondingly, in some embodiments, the thickness of the cover may be thicker in regions where it is desired for more liquid to be leaked or otherwise emitted before the liquid leak detection system is actuated. In other words, the thickness of the cover may be used to control the sensitivity of the leak detectors (or other portions of the liquid leak detection systems) thereunder. Similarly, in some embodiments, the liquid lead detection system may even include regions that are covered by a cover and other regions that are not covered by a cover. Further illustrative, non-exclusive examples of mechanisms for defining the sensitivity of localized regions of the liquid leak detection system may selectively, or non-uniformly, applying hydrophobic (or other water-repelling) coatings to the cover, distributing conductive particulate on or within the cover, forming the cover from different materials, etc. By using one or more coatings or materials having different permeabilities for different liquids, the liquid leak detector system may be configured to be actuated by some liquids and not to be actuated by others because the others (which may not have a predetermined property) are not permitted to contact, or sufficiently contact, the liquid sensor.
In some embodiments, the cover may be configured so that a predetermined volume of liquid will actuate the liquid leak detection system, such as if emitted or otherwise deposited upon the cover and/or a liquid detector. In some embodiments, the liquid leak detection system may be configured to be more sensitive, or designed to detect, a liquid having a predetermined property than a liquid that does not have this property. As an illustrative, non-exclusive example, by using a hydrophobic coating, layer, or other material in the cover, the liquid leak detection system may be configured to inhibit water passing through the cover to the liquid detector. In such an embodiment, the liquid leak detection system may be configured to be actuated (i.e., detect a liquid leak) upon receipt of at least a predetermined volume of a liquid carbon-containing feedstock, but not to be actuated upon receipt of an equal volume of water.
As an illustrative, non-exclusive example, the controller may be configured to detect whether a closed circuit is formed between two of the conductive members, which nominally (i.e., when not bridged by leaked liquid) define an open circuit. For example, and as somewhat schematically illustrated in
In a variation of this electrical conductive embodiment, at least one conductive member of the plurality of conductive members 190 may be partially or completely sheathed or encased by, or otherwise inserted within, cover 180. This is schematically illustrated in
Illustrative, non-exclusive examples of suitable constructions for conductive members 190 include screens (or other perforated sheets, meshes, or expanded metal members) and wires. In
Insulating material 202 should be permeable to at least the carbon-containing feedstock portion of any liquid that may be emitted to the cover from the fuel processing system, and in some embodiments may be partially or completely permeable to water. The liquid permeability of the insulating material may be inherent in the composition of the insulating material, such as if the material is porous, absorptive, or the like. Additionally or alternatively, the insulating material may have one or more passages 206 formed therein to define potential flow paths for liquid to pass through the insulating material, such as via capillary action, via gravity flow, etc. An illustrative, non-exclusive example of such a construction is shown in
The screens and insulating material may have any suitable shape and size, including planar, curved, and other shapes. In some embodiments, the screens, insulating material, and/or cover (when present) may be shaped to generally conform to a supporting base and/or to the components of the fuel processing system beneath which these components are positioned. In some embodiments, at least the cover for the screens or other conductive members may be concave, trough-shaped, or otherwise shaped to define one or more liquid-pooling regions into which leaked liquid that encounters the cover will flow.
Similar to previously discussed embodiments, the cover and/or insulating material may be formed from liquid-permeable materials and/or may include defined passages through which liquid may pass even if the cover and/or insulating material is formed from (or is otherwise treated or coated to be) impermeable to water and/or carbon-containing feedstock. Illustrative, non-exclusive examples of these options are somewhat schematically illustrated in
As discussed herein, the various components of the liquid leak detection system should be selected so as to be chemically and physically stable and suitable for use in the operating environment of the fuel processing system, including at the elevated temperatures and/or pressures encountered during use of the fuel processing system and/or the potential for being exposed to the various liquid and/or gaseous fluids present in the fuel processing system. Illustrative, non-exclusive examples of suitable insulating materials include (but are not limited to) ceramics, high-temperature felts, alumina, and the like. Furthermore, it is within the scope of the present disclosure that a single controller 164 may be utilized with two or more liquid detectors 162. Similarly, where the liquid detectors utilize an electrical ground, it is within the scope of the present disclosure that the housing or shell of the fuel processing system may (but is not required to) be this ground.
As discussed, in many applications it is desirable for the fuel processor to produce at least substantially pure hydrogen gas. Accordingly, the fuel processor may utilize a process that inherently produces sufficiently pure hydrogen gas. When the output stream contains sufficiently pure hydrogen gas and/or sufficiently low concentrations of one or more non-hydrogen components for a particular application, product hydrogen stream 14 may be formed directly from output stream 20. However, in many hydrogen-producing processes, output stream 20 will be a mixed gas stream that contains hydrogen gas as a majority component along with other gases. Similarly, in many applications, the output stream 20 may be substantially pure hydrogen but still contain concentrations of one or more non-hydrogen components that are harmful or otherwise undesirable in the application for which the product hydrogen stream is intended to be used.
Accordingly, fuel processing system 10 may (but is not required to) further include a purification region 24, in which a hydrogen-rich stream 26 is produced from the output, or mixed gas, stream. Hydrogen-rich stream 26 contains at least one of a greater hydrogen concentration than output stream 20 and a reduced concentration of one or more of the other gases or impurities that were present in the output stream. Purification region 24 is schematically illustrated in
Purification region 24 may, but is not required to, produce at least one byproduct stream 28. Byproduct stream 28 contains at least one of a lower concentration of hydrogen gas and a greater concentration of one or more of the other gases or impurities that were present in the output stream. Byproduct stream 28 may (but is not required to) contain some hydrogen gas. When present, byproduct stream 28 may be exhausted, sent to a burner assembly or other combustion source, used as a heated fluid stream, stored for later use, or otherwise utilized, stored or disposed of. It is within the scope of the disclosure that byproduct stream 28 may be emitted from the purification region as a continuous stream responsive to the delivery of output stream 20 to the purification region, or intermittently, such as in a batch process or when the byproduct portion of the output stream is retained at least temporarily in the purification region.
Purification region 24 includes any suitable device, or combination of devices, that are adapted to reduce the concentration of at least one component of output stream 20. In most applications, hydrogen-rich stream 26 will have a greater hydrogen concentration than output, or mixed gas, stream 20. However, it is also within the scope of the disclosure that the hydrogen-rich stream will have a reduced concentration of one or more non-hydrogen components that were present in output stream 20, yet have the same, or even a reduced overall hydrogen concentration as the output stream. For example, in some applications where product hydrogen stream 14 may be used, certain impurities, or non-hydrogen components, are more harmful than others. As a specific example, in many conventional fuel cell systems, carbon monoxide may damage a fuel cell stack if it is present in even a few parts per million, while other non-hydrogen components that may be present in stream 20, such as water, will not damage the stack even if present in much greater concentrations. Therefore, in such an application, a suitable purification region may not increase the overall hydrogen concentration, but it will reduce the concentration of a non-hydrogen component that is harmful, or potentially harmful, to the desired application for the product hydrogen stream.
Illustrative examples of suitable devices for purification region 24 include one or more hydrogen-selective membranes 30, chemical carbon monoxide removal assemblies 32, and pressure swing adsorption systems 38. It is within the scope of the disclosure that purification region 24 may include more than one type of purification device, and that these devices may have the same or different structures and/or operate by the same or different mechanisms. As discussed, hydrogen-producing fuel processing system 10 may include at least one restrictive orifice or other flow restrictor downstream of at least one purification region, such as associated with one or more of the product hydrogen stream, hydrogen-rich stream, and/or byproduct stream.
Hydrogen-selective membranes 30 are permeable to hydrogen gas, but are at least substantially, if not completely, impermeable to other components of output stream 20. Membranes 30 may be formed of any hydrogen-selective material suitable for use in the operating environment and parameters in which purification region 24 is operated. Examples of suitable materials for membranes 30 include palladium and palladium alloys, and especially thin films of such metals and metal alloys. Palladium alloys have proven particularly effective, especially palladium with 35 wt % to 45 wt % copper. A palladium-copper alloy that contains approximately 40 wt % copper has proven particularly effective, although other relative concentrations and components may be used within the scope of the disclosure.
Hydrogen-selective membranes are typically formed from a thin foil that is approximately 0.001 inches thick. It is within the scope of the present disclosure, however, that the membranes may be formed from other hydrogen-permeable and/or hydrogen-selective materials, including metals and metal alloys other than those discussed above as well as non-metallic materials and compositions, and that the membranes may have thicknesses that are greater or less than discussed above. For example, the membrane may be made thinner, with commensurate increase in hydrogen flux. Examples of suitable mechanisms for reducing the thickness of the membranes include rolling, sputtering and etching. A suitable etching process is disclosed in U.S. Pat. No. 6,152,995, the complete disclosure of which is hereby incorporated by reference for all purposes. Examples of various membranes, membrane configurations, and methods for preparing the same are disclosed in U.S. Pat. Nos. 6,221,117, 6,319,306, and 6,537,352, the complete disclosures of which are hereby incorporated by reference for all purposes.
Chemical carbon monoxide removal assemblies 32 are devices that chemically react carbon monoxide and/or other undesirable components of output stream 20, if present in output stream 20, to form other compositions that are not as potentially harmful. Examples of chemical carbon monoxide removal assemblies include water-gas shift reactors and other devices that convert carbon monoxide to carbon dioxide, and methanation catalyst beds that convert carbon monoxide and hydrogen to methane and water. It is within the scope of the disclosure that fuel processing assembly 10 may include more than one type and/or number of chemical removal assemblies 32.
Pressure swing adsorption (PSA) is a chemical process in which gaseous impurities are removed from output stream 20 based on the principle that certain gases, under the proper conditions of temperature and pressure, will be adsorbed onto an adsorbent material more strongly than other gases. Typically, it is the impurities that are adsorbed and removed from output stream 20. The success of using PSA for hydrogen purification is due to the relatively strong adsorption of common impurity gases (such as CO, CO2, hydrocarbons including CH4, and N2) on the adsorbent material. Hydrogen adsorbs only very weakly and so hydrogen passes through the adsorbent bed while the impurities are retained on the adsorbent material. Impurity gases such as NH3, H2S, and H2O adsorb very strongly on the adsorbent material and are removed from stream 20 along with other impurities. If the adsorbent material is going to be regenerated and these impurities are present in stream 20, purification region 24 preferably includes a suitable device that is adapted to remove these impurities prior to delivery of stream 20 to the adsorbent material because it is more difficult to desorb these impurities.
Adsorption of impurity gases occurs at elevated pressure. When the pressure is reduced, the impurities are desorbed from the adsorbent material, thus regenerating the adsorbent material. Typically, PSA is a cyclic process and requires at least two beds for continuous (as opposed to batch) operation. Examples of suitable adsorbent materials that may be used in adsorbent beds are activated carbon and zeolites, especially 5 521 (5 angstrom) zeolites. The adsorbent material is commonly in the form of pellets and it is placed in a cylindrical pressure vessel utilizing a conventional packed-bed configuration. Other suitable adsorbent material compositions, forms, and configurations may be used.
PSA system 38 also provides an example of a device for use in purification region 24 in which the byproducts, or removed components, are not directly exhausted from the region as a gas stream concurrently with the purification of the output stream. Instead, these byproduct components are removed when the adsorbent material is regenerated or otherwise removed from the purification region.
It is further within the scope of the disclosure that one or more of the components of fuel processing system 10 may either extend beyond the shell or be located external at least shell 68. For example, and as discussed, purification region 24 may be located external shell 68, such as with the purification region being coupled directly to the shell (as schematically illustrated in
In the context of a fuel processor, or fuel processing assembly, that is adapted to produce a product hydrogen stream that will be used as a feed, or fuel, stream for a fuel cell stack, the fuel processor preferably is adapted to produce substantially pure hydrogen gas, and even more preferably, the fuel processor is adapted to produce pure hydrogen gas. For the purposes of the present disclosure, substantially pure hydrogen gas is greater than 90% pure, preferably greater than 95% pure, more preferably greater than 99% pure, and even more preferably greater than 99.5% pure. Suitable fuel processors and fuel processing assemblies, including illustrative (non-exclusive) examples of components and configurations therefor for producing streams of at least substantially pure hydrogen gas are disclosed in U.S. Pat. Nos. 6,319,306, 6,221,117, 5,997,594, 5,861,137, and U.S. Patent Application Publication Nos. 2001/0045061, 2003/0192251, 2003/0223926, and 2006/0090397. The complete disclosures of the above-identified patents and patent applications are hereby incorporated by reference for all purposes.
As discussed, product hydrogen stream 14 may be used in a variety of applications, including applications where high purity hydrogen gas is utilized. An example of such an application is as a fuel, or feed, stream for a fuel cell stack. A fuel cell stack is a device that produces an electrical potential from a source of protons, such as hydrogen gas, and an oxidant, such as oxygen gas. Accordingly, a fuel cell stack may be adapted to receive at least a portion of product hydrogen stream 14 and a stream of oxygen (which is typically delivered as an air stream), and to produce an electric current therefrom. This is schematically illustrated in
When product hydrogen stream 14 is intended for use in a fuel cell stack, compositions that may damage the fuel cell stack, such as carbon monoxide and carbon dioxide, may be removed from the hydrogen-rich stream, if necessary, such as by purification region 24. For some fuel cell stacks, such as proton exchange membrane (PEM) and alkaline fuel cell stacks, it may be desirable for the concentration of carbon monoxide to be less than 10 ppm (parts per million), less than 5 ppm, or even less than 1 ppm. The concentration of carbon dioxide may be greater than that of carbon monoxide. For example, concentrations of less than 25% carbon dioxide may be acceptable in some embodiments. For some fuel cell stacks, it may be desirable for the concentration of carbon dioxide to be less than 10%, less than 1%, or even less than 50 ppm. The acceptable minimum concentrations presented herein are illustrative examples, and concentrations other than those presented herein may be used and are within the scope of the present disclosure. For example, particular users or manufacturers may require minimum or maximum concentration levels or ranges that are different than those identified herein.
Fuel cell stack 40 contains at least one, and typically multiple, fuel cells 44 that are adapted to produce an electric current from an oxidant, such as air, oxygen-enriched air, or oxygen gas, and the portion of the product hydrogen stream 14 delivered thereto. A fuel cell stack typically includes multiple fuel cells joined together between common end plates 48, which contain fluid delivery/removal conduits, although this construction is not required to all embodiments. Examples of suitable fuel cells include proton exchange membrane (PEM) fuel cells and alkaline fuel cells. Others include solid oxide fuel cells, phosphoric acid fuel cells, and molten carbonate fuel cells.
The electric current, or electrical output, produced by stack 40 may be used to satisfy the energy demands, or applied load, of at least one associated energy-consuming device 46. Illustrative examples of devices 46 include, but should not be limited to, motor vehicles, recreational vehicles, construction or industrial vehicles, boats or other seacraft, tools, lights or lighting assemblies, appliances (such as household or other appliances), households or other dwellings, offices or other commercial establishments, computers, signaling or communication equipment, battery chargers, etc. Similarly, fuel cell stack 40 may be used to satisfy the power requirements of fuel cell system 42, which may be referred to as the balance-of-plant power requirements of the fuel cell system. It should be understood that device 46 is schematically illustrated in
Fuel cell stack 40 may receive all of product hydrogen stream 14. Some or all of stream 14 may additionally, or alternatively, be delivered, via a suitable conduit, for use in another hydrogen-consuming process, burned for fuel or heat, or stored for later use. As an illustrative example, a hydrogen storage device 50 is shown in dashed lines in
Fuel cell system 42 may also include at least one energy-storage device 51 that is adapted to store the electric potential, or power output, produced by fuel cell stack 40. Illustrative, non-exclusive examples of other energy storage devices that may be used include a battery 52, flywheels, and capacitors, such as ultracapacitors or supercapacitors. Similar to the above discussion regarding excess hydrogen gas, fuel cell stack 40 may produce a power output in excess of that necessary to satisfy the load exerted, or applied, by energy-consuming device 46, including the load required to power fuel cell system 42. In further similarity to the above discussion of excess hydrogen gas, this excess power output may be used in other applications outside of the fuel cell system and/or stored for later use by the fuel cell system. For example, the battery or other storage device may provide power for use by fuel cell system 42 during startup or other applications in which the system is not producing electricity and/or hydrogen gas. In
As indicated in dashed lines in
Fuel processors 12, feedstock delivery systems 22, heating assemblies 60, and liquid leak detection systems 160 according to the present disclosure may be configured in any of the arrangements described, illustrated and/or incorporated herein. In some embodiments, features or aspects from one or more of the above described configurations may be combined with each other and/or with additional features described herein. For example, it is within the scope of the present disclosure that fuel processing systems 10 that include at least one purification region 24 may (but are not required to) house the hydrogen-producing region 19 and at least a portion of the purification region together in a common housing, with this housing optionally being located within the shell 68 of the fuel processor. This is schematically illustrated in
As indicated in dashed lines in
Many hydrogen-producing fuel processors, such as steam and autothermal reformers and pyrolysis and partial oxidation reactors, utilize a carbon-containing feedstock that is used in the hydrogen-producing reaction, and then a separate fuel stream, which typically also includes a carbon-containing feedstock, that is used as a fuel source for the heating assembly. As such, these conventional fuel processing assemblies require a separate source, pump, or other delivery assembly, transport conduits, and flow-regulating devices, etc. According to an aspect of the present disclosure, which is not required to all embodiments, a liquid-phase carbon-containing feedstock 84 may be used for both carbon-containing feedstock portion 18 of feed stream 16 for reforming region 19 and carbon-containing feedstock portion 65 of fuel stream 64 for heating assembly 60, such as schematically illustrated in
In the illustrative example shown in
The distribution of liquid carbon-containing feedstock 84 between the hydrogen-producing region and the heating assembly may be manually controlled. However, in many embodiments, it may be desirable for the distribution to be predetermined and/or at least partially automated, such as by including a controller 88 that selectively regulates the delivery of feedstock 84 between the hydrogen-producing region and the heating assembly. An example of a suitable controller for a steam reforming fuel processor is disclosed in U.S. Pat. No. 6,383,670, the complete disclosure of which is hereby incorporated by reference. In some embodiments, controller 88 and/or valve assembly 86 may be configured to allow a predetermined initial volume of carbon-containing feedstock into heating assembly 60, as will be discussed in greater detail herein.
As discussed previously, in the context of a steam reformer or other fuel processor that produces hydrogen gas from water and a carbon-containing feedstock, feed stream 16 may be at least substantially, and typically entirely, comprised of a mixture of water and a liquid-phase carbon-containing feedstock 84 that is preferably miscible in, or with, water. As such, a single (composite) feed stream 90 containing water 17 and carbon-containing feedstock 84 can be consumed as both the hydrogen-producing feed stream 16 for the reforming reaction, as well as the heating assembly fuel stream 64. Further reduction in the supplies, delivery systems, flow regulators, delivery conduits and the like may be achieved according to another aspect of the present disclosure by feed stream 16 and fuel stream 64 both containing the same liquid carbon-containing feedstock 84 and water 17, with the carbon-containing feedstock preferably being miscible in water. This is schematically illustrated in
Similar to the previously discussed alternatives of
The relative amounts of water 17 and liquid carbon-containing feedstock 84 in composite feed stream 90 may vary within the scope of the present disclosure. For example, the ratio may depend upon such factors as the particular carbon-containing feedstock being used, the hydrogen-producing mechanism being used in the fuel processor, user preferences, the catalyst being utilized, the demand for hydrogen gas, the efficiency of the reforming catalyst, etc. The relative concentrations of these components may be expressed in terms of a ratio of water to carbon. When feedstock 84 is methanol, a 1:1 molar ratio of steam to carbon has proven effective. When feedstock 84 is ethanol, a ratio of 2-3:1 has proven effective. When feedstock 84 is a hydrocarbon, a ratio of approximately 3:1 is typically used. However, the illustrative ratios described above are not meant to be exclusive ratios within the scope of the disclosure, and others, including greater and lesser ratios, may be used.
Illustrative examples of hydrogen-producing fuel cell systems 42, hydrogen-producing fuel processing systems 10, feedstock delivery systems 22, liquid leak detection systems 160, and heating assemblies 60 have been schematically illustrated in various ones of
It is also within the scope of the present disclosure that the liquid leak detection systems disclosed herein may be utilized in other applications where it is desirable, or even necessary, to detect liquid leaks. As discussed, in some embodiments, the liquid that may be leaked is a combustible liquid. In some embodiments, the liquid leak detection systems may be used to detect liquid leaks of non-water liquids, leaks of non-water liquids in environments or applications where water may be present, and/or non-water liquid portions of water-containing liquid mixtures. Illustrative, non-exclusive examples include using the liquid leak detection systems that are described, illustrated, and/or incorporated herein to detect liquid leaks at or around storage vessels and storage apparatus for liquid fuels and/or combustible liquids. Additional illustrative, non-exclusive examples include using the liquid leak detection systems that are described, illustrated, and/or incorporated herein to detect liquid leaks at or around fluid distribution conduits for liquid fuels or combustible liquid streams.
As another illustrative, non-exclusive example, liquid leak detection systems 160 according to the present disclosure may be utilized with direct methanol fuel cell systems. In a direct methanol fuel cell system, methanol is not consumed in a catalytic reforming reaction to produce hydrogen gas. Instead, methanol and water are consumed directly by the fuel cell stack to produce an electrical output (and water). Specifically, methanol is oxidized in a catalyst-containing anode region of a direct methanol fuel cell to produce carbon dioxide. Liberated protons may pass through the electrolytic membrane, or barrier, to the air-containing (or other oxidant-containing) cathode region, where water is formed. Liberated electrons cannot pass through the electrolytic barrier and instead travel through an external circuit. Similar to the above discussion about providing solutions of methanol and/or methanol and water to a hydrogen-producing region and/or heating assembly of a hydrogen-producing fuel processing assembly, direct methanol fuel cell systems also require a feedstock delivery system to deliver at least methanol, and often methanol and water, to a direct methanol fuel cell, or fuel cell stack.
A direct methanol fuel cell system that includes a liquid leak detection system according to the present disclosure is schematically illustrated in
Liquid leak detection system 160 is schematically illustrated in
The liquid leak detection systems, and hydrogen-producing fuel processing and fuel cell systems containing the same, that are disclosed herein are applicable to the hydrogen-production industries and to the energy-production industries, including the fuel cell industries.
The disclosure set forth above encompasses multiple distinct inventions with independent utility. While each of these inventions has been disclosed in a preferred form or method, the specific alternatives, embodiments, and/or methods thereof as disclosed and illustrated herein are not to be considered in a limiting sense, as numerous variations are possible. The present disclosure includes all novel and non-obvious combinations and subcombinations of the various elements, features, functions, properties, methods and/or steps disclosed herein. Similarly, where any disclosure above or claim below recites “a” or “a first” element, step of a method, or the equivalent thereof, such disclosure or claim should be understood to include one or more such elements or steps, neither requiring nor excluding two or more such elements or steps.
Inventions embodied in various combinations and subcombinations of features, functions, elements, properties, steps and/or methods may be claimed through presentation of new claims in a related application. Such new claims, whether they are directed to a different invention or directed to the same invention, whether different, broader, narrower, or equal in scope to the original claims, are also regarded as included within the subject matter of the present disclosure.
|Cited Patent||Filing date||Publication date||Applicant||Title|
|US2824620||12 Sep 1955||25 Feb 1958||Universal Oil Prod Co||Purification of hydrogen utilizing hydrogen-permeable membranes|
|US3094391||22 Apr 1960||18 Jun 1963||Kellogg M W Co||Hydrocarbon conversion|
|US3144312||6 Jun 1961||11 Aug 1964||Mertens Carl||Catalytic conversion plant for the continuous generation of gases of any kind out of ydrocarbons|
|US3336730||17 Nov 1964||22 Aug 1967||Union Carbide Corp||Hydrogen continuous production method and apparatus|
|US3338681||18 Dec 1963||29 Aug 1967||Union Carbide Corp||Apparatus for hydrogen generation|
|US3350176||24 Mar 1964||31 Oct 1967||Engelhard Ind Inc||Hydrogen generator|
|US3469944||13 May 1968||30 Sep 1969||Bertrand J Mayland||Process and apparatus for the manufacture of hydrogen for fuel cells|
|US3522019||18 Mar 1968||28 Jul 1970||United Aircraft Corp||Apparatus for generating hydrogen from liquid hydrogen - containing feedstocks|
|US3655448||22 May 1969||11 Apr 1972||United Aircraft Corp||Hydrogen generator desulfurizer employing feedback ejector|
|US3761382||21 Jun 1972||25 Sep 1973||Triangle Environment Corp||Ers and the like apparatus for generating purifying and delivering hydrogen for analyz|
|US3787038||7 Nov 1972||22 Jan 1974||A Ivanoy||Reformer for firing reverberatory furnace and method of operating said reformer|
|US3920416||26 Dec 1973||18 Nov 1975||California Inst Of Techn||Hydrogen-rich gas generator|
|US3955941||10 Feb 1975||11 May 1976||California Institute Of Technology||Hydrogen rich gas generator|
|US3982910||10 Jul 1974||28 Sep 1976||The United States Of America As Represented By The Administrator Of The National Aeronautics And Space Administration||Hydrogen-rich gas generator|
|US4033133||22 Mar 1976||5 Jul 1977||California Institute Of Technology||Start up system for hydrogen generator used with an internal combustion engine|
|US4071330||22 Dec 1976||31 Jan 1978||United Technologies Corporation||Steam reforming process and apparatus therefor|
|US4079586||21 Apr 1976||21 Mar 1978||Kincaid Jr Elmo||Automatic steam pressure generator|
|US4084934||30 May 1975||18 Apr 1978||Mitsubishi Precision Co., Ltd.||Combustion apparatus|
|US4098587||25 Aug 1977||4 Jul 1978||United Technologies Corporation||Compact multi-tube catalytic reaction apparatus|
|US4098588||25 Aug 1977||4 Jul 1978||United Technologies Corporation||Multi-tube catalytic reaction apparatus|
|US4098589||25 Aug 1977||4 Jul 1978||United Technologies Corporation||Catalytic reaction apparatus|
|US4098959||27 Dec 1976||4 Jul 1978||United Technologies Corporation||Fuel cell fuel control system|
|US4098960||27 Dec 1976||4 Jul 1978||United Technologies Corporation||Fuel cell fuel control system|
|US4134739||21 Mar 1977||16 Jan 1979||Siemens Aktiengesellschaft||Starting device for a reformed gas generator|
|US4175165||20 Jul 1977||20 Nov 1979||Engelhard Minerals & Chemicals Corporation||Fuel cell system utilizing ion exchange membranes and bipolar plates|
|US4179879||9 Feb 1978||25 Dec 1979||Kincaid Elmo Jr||Automatic steam pressure generator|
|US4203950||27 Dec 1977||20 May 1980||United Technologies Corporation||Steam reforming reactor designed to reduce catalyst crushing|
|US4214969||2 Jan 1979||29 Jul 1980||General Electric Company||Low cost bipolar current collector-separator for electrochemical cells|
|US4238403||6 Feb 1978||9 Dec 1980||Imperial Chemical Industries Limited||Methanol synthesis process|
|US4278445||31 May 1979||14 Jul 1981||Avco Everett Research Laboratory, Inc.||Subsonic-velocity entrained-bed gasification of coal|
|US4278446||31 May 1979||14 Jul 1981||Avco Everett Research Laboratory, Inc.||Very-high-velocity entrained-bed gasification of coal|
|US4292274||4 Aug 1980||29 Sep 1981||United Technologies Corporation||Catalytic reactor with improved burner|
|US4302177||5 Jun 1978||24 Nov 1981||The M. W. Kellogg Company||Fuel conversion apparatus and method|
|US4331520||26 Oct 1979||25 May 1982||Prototech Company||Process for the recovery of hydrogen-reduced metals, ions and the like at porous hydrophobic catalytic barriers|
|US4389326||12 Jun 1981||21 Jun 1983||Agence Nationale De Valorization De La Recherche||Method of storing hydrogen in intimate mixtures of hydrides of magnesium and other metals or alloys|
|US4400182||19 Jul 1982||23 Aug 1983||British Gas Corporation||Vaporization and gasification of hydrocarbon feedstocks|
|US4408572||16 Jun 1982||11 Oct 1983||Conoco Inc.||Ether cold starter in alcohol fuel treatment and distribution apparatus and method|
|US4430304||13 Nov 1981||7 Feb 1984||The United States Of America As Represented By The United States Department Of Energy||Slab reformer|
|US4444158||3 Sep 1982||24 Apr 1984||Conoco Inc.||Alcohol dissociation process for automobiles|
|US4468235||7 Feb 1983||28 Aug 1984||Hill Eugene F||Hydrogen separation using coated titanium alloys|
|US4473622||27 Dec 1982||25 Sep 1984||Chludzinski Paul J||Rapid starting methanol reactor system|
|US4476674||10 Jun 1982||16 Oct 1984||Westinghouse Electric Corp.||Power generating plant employing a reheat pressurized fluidized bed combustor system|
|US4504447||27 Oct 1983||12 Mar 1985||The United States Of America As Represented By The United States Department Of Energy||Slab reformer|
|US4506631||22 Jun 1983||26 Mar 1985||Lawrence Waldemar Ihnativ||Process to produce hydrogen and oxygen utilizing the energy content of waste materials|
|US4509915||9 Sep 1982||9 Apr 1985||Osaka Gas Company Limited||Liquid fuel combustion apparatus|
|US4533607||6 Dec 1984||6 Aug 1985||United Technologies Corporation||Process for removing electrolyte vapor from fuel cell exhaust gas|
|US4567857||16 Aug 1982||4 Feb 1986||The United States Of America As Represented By The Administrator Of The National Aeronautics And Space Administration||Combustion engine system|
|US4642273||13 Jun 1985||10 Feb 1987||Mitsubishi Denki Kabushiki Kaisha||Reformer reaction control apparatus for a fuel cell|
|US4657828||8 Apr 1986||14 Apr 1987||Fuji Electric Company Ltd.||Fuel cell system|
|US4659634||3 Feb 1986||21 Apr 1987||Struthers Ralph C||Methanol hydrogen fuel cell system|
|US4670359||10 Jun 1985||2 Jun 1987||Engelhard Corporation||Fuel cell integrated with steam reformer|
|US4687491||23 Feb 1984||18 Aug 1987||Dresser Industries, Inc.||Fuel admixture for a catalytic combustor|
|US4692306||24 Mar 1986||8 Sep 1987||Kinetics Technology International Corporation||Catalytic reaction apparatus|
|US4699637||10 Sep 1984||13 Oct 1987||Kernforschungsanlage Julich Gesellschaft Mit Beschrankter Haftung||Hydrogen permeation membrane|
|US4788004||20 May 1987||29 Nov 1988||Imperial Chemical Industries Plc||Catalytic process|
|US4820594||9 Feb 1987||11 Apr 1989||Hitachi, Ltd.||Method of starting fuel cell power generation system|
|US4838897||9 Nov 1987||13 Jun 1989||Hitachi, Ltd.||Reformer|
|US4849187||28 Mar 1988||18 Jul 1989||Toyo Engineering Corporation||Steam reforming apparatus|
|US4877923 *||17 Aug 1988||31 Oct 1989||W. L. Gore & Associates, Inc.||Sensors for detecting and locating liquid leaks|
|US4926165 *||11 Mar 1986||15 May 1990||Raychem Corporation||Devices for detecting and obtaining information about an event|
|US4981676||13 Nov 1989||1 Jan 1991||Minet Ronald G||Catalytic ceramic membrane steam/hydrocarbon reformer|
|US4988286||14 Mar 1989||29 Jan 1991||Electric Power Technologies, Inc.||Smokeless ignitor|
|US5198312||13 Mar 1991||30 Mar 1993||Mitsubishi Jukogyo Kabushiki Kaisha||Power generation system with flat fuel cells of solid electrolyte|
|US5226928||24 Dec 1990||13 Jul 1993||The Tokyo Electric Power Company, Incorporated||Reforming apparatus for hydrocarbon|
|US5229102||27 Dec 1990||20 Jul 1993||Medalert, Inc.||Catalytic ceramic membrane steam-hydrocarbon reformer|
|US5401589||22 Nov 1991||28 Mar 1995||Vickers Shipbuilding And Engineering Limited||Application of fuel cells to power generation systems|
|US5432710||29 Mar 1993||11 Jul 1995||Osaka Gas Company Limited||Energy supply system for optimizing energy cost, energy consumption and emission of pollutants|
|US5458857||22 Nov 1993||17 Oct 1995||Rolls-Royce, Plc||Combined reformer and shift reactor|
|US5470360||10 Mar 1994||28 Nov 1995||International Fuel Cells Corporation||Fuel cell power plant reformer burner gas flow control system|
|US5516344||10 Jan 1992||14 May 1996||International Fuel Cells Corporation||Fuel cell power plant fuel processing apparatus|
|US5616430||15 Aug 1995||1 Apr 1997||Toyota Jidosha Kabushiki Kaisha||Reformer and fuel cell system using the same|
|US5628931||7 Jul 1995||13 May 1997||Shell Oil Company||Process for the preparation of hydrogen and carbon monoxide containing mixtures|
|US5637414||20 May 1996||10 Jun 1997||Fuji Electric Co., Ltd.||Method and system for controlling output of fuel cell power generator|
|US5639431||16 Mar 1994||17 Jun 1997||Tokyo Gas Co. Ltd.||Hydrogen producing apparatus|
|US5714276||11 Oct 1996||3 Feb 1998||Honda Giken Kogyo Kabushiki Kaisha||Method for supplying fuel gas to fuel cell assembly|
|US5729967||16 Aug 1996||24 Mar 1998||Abb Research Ltd.||Method of operating a gas turbine on reformed fuel|
|US5744067||19 Oct 1994||28 Apr 1998||Texaco Inc.||Production of H2 -rich gas|
|US5780179||25 Jun 1996||14 Jul 1998||Honda Giken Kogyo Kabushiki Kaisha||Fuel cell system for use on mobile bodies|
|US5798186||7 Jun 1996||25 Aug 1998||Ballard Power Systems Inc.||Method and apparatus for commencing operation of a fuel cell electric power generation system below the freezing temperature of water|
|US5811065||24 Apr 1997||22 Sep 1998||Ballard Generation Systems Inc.||Burner exhaust gas collection assembly for a catalytic reformer|
|US5833723||26 Feb 1996||10 Nov 1998||Aisin Seiki Kabushiki Kaisha||Hydrogen generating apparatus|
|US5851689||23 Jan 1997||22 Dec 1998||Bechtel Corporation||Method for operating a fuel cell assembly|
|US5861137||30 Oct 1996||19 Jan 1999||Edlund; David J.||Steam reformer with internal hydrogen purification|
|US5932141||22 Jan 1998||3 Aug 1999||Haldor Topsoe A/S||Synthesis gas production by steam reforming using catalyzed hardware|
|US5938800||13 Nov 1997||17 Aug 1999||Mcdermott Technology, Inc.||Compact multi-fuel steam reformer|
|US5997594||15 Oct 1997||7 Dec 1999||Northwest Power Systems, Llc||Steam reformer with internal hydrogen purification|
|US5998053||5 Jun 1997||7 Dec 1999||Sulzer Hexis Ag||Method for operating an apparatus with fuel cells|
|US6042956||23 Jun 1997||28 Mar 2000||Sulzer Innotec Ag||Method for the simultaneous generation of electrical energy and heat for heating purposes|
|US6045772||19 Aug 1998||4 Apr 2000||International Fuel Cells, Llc||Method and apparatus for injecting a liquid hydrocarbon fuel into a fuel cell power plant reformer|
|US6045933||27 Jan 1998||4 Apr 2000||Honda Giken Kogyo Kabushiki Kaisha||Method of supplying fuel gas to a fuel cell|
|US6077620||26 Nov 1997||20 Jun 2000||General Motors Corporation||Fuel cell system with combustor-heated reformer|
|US6083637||25 Feb 1998||4 Jul 2000||Daimlerchrysler Ag||Fuel cell energy generating system|
|US6103411||26 May 1998||15 Aug 2000||Sanyo Electric Co., Lted.||Hydrogen production apparatus and method operable without supply of steam and suitable for fuel cell systems|
|US6123873||12 Feb 1999||26 Sep 2000||Haldor Topsoe A/S||Method for soot-free start-up of autothermal reformers|
|US6124053||9 Jul 1998||26 Sep 2000||Fuel Cell Technologies, Inc.||Fuel cell with internal combustion chamber|
|US6152995||22 Mar 1999||28 Nov 2000||Idatech Llc||Hydrogen-permeable metal membrane and method for producing the same|
|US6165633||14 Feb 1997||26 Dec 2000||Toyota Jidosha Kabushiki Kaisha||Method of and apparatus for reforming fuel and fuel cell system with fuel-reforming apparatus incorporated therein|
|US6180272||20 Aug 1998||30 Jan 2001||Lucent Technologies Inc.||System and method for automatically providing fuel to a fuel cell in response to a power failure in a primary power system|
|US6183895||2 Jul 1997||6 Feb 2001||Matsushita Electric Works, Ltd.||Fuel-cell power generating system|
|US6187066||24 Sep 1997||13 Feb 2001||Daimlerchrysler Ag||Central heating device for a gas-generating system|
|US6656617 *||12 Jan 2001||2 Dec 2003||Toyota Jidosha Kabushiki Kaisha||Fuel gas production system for fuel cells|
|US20020122966 *||2 Mar 2001||5 Sep 2002||Acker William P.||Cold start and temperature control method and apparatus for fuel cell system|
|US20040043263 *||25 Aug 2003||4 Mar 2004||Casio Computer Co., Ltd.||Reformer, method for manufacturing the reformer, and power generation system|
|US20040161642 *||12 Feb 2004||19 Aug 2004||Kabushiki Kaisha Toshiba||Electronic equipment and fuel cell for the same|
|US20040234828 *||22 Mar 2004||25 Nov 2004||Kabushiki Kaisha Toshiba||Electronic apparatus, fuel cell unit, and method of controlling the operation of the electronic apparatus|
|US20050074644 *||30 Sep 2004||7 Apr 2005||Matsushita Electric Industrial Co., Ltd.||Fuel cell system|
|US20070193342 *||17 Feb 2006||23 Aug 2007||Bailey Douglas S||Sensor for detecting hydrocarbons|
|USRE35002||15 Aug 1994||25 Jul 1995||Yamaha Hatsudoki Kabushiki Kaisha||Fuel cell system|
|1||Emonts, B., et al., "Compact Methanol Reformer Test for Fuel-Cell Powered Light-Duty Vehicles," Fifth Grove Fuel Cell Symposium, Commonwealth Institute, London, U.K., p. 42 (Sep. 22-25, 1997).|
|2||English-language abstract of Great Britain Patent No. 2,305,186, 1997.|
|3||English-language abstract of Japanese Patent No. 4-338101, 1992.|
|4||English-language abstract of Japanese Patent No. 5132301, 1993.|
|5||English-language abstract of Japanese Patent No. 5147902, 1993.|
|6||English-language abstract of Japanese Patent No. 57-145276, 1982.|
|7||English-language abstract of Japanese Patent No. 710910, 1995.|
|8||English-language abstract of Japanese Patent No. 8287932, 1996.|
|9||Fig. 1 of Taiwan Patent Publication No. 301473, undated, which was cited in a communication received Jul. 21, 2004 from a foreign patent office.|
|Citing Patent||Filing date||Publication date||Applicant||Title|
|US8020430 *||9 Oct 2008||20 Sep 2011||Toyota Motor Engineering & Manufacturing North America, Inc.||Passive leak detection devices and systems for detecting gas leaks|
|US9064401 *||7 May 2013||23 Jun 2015||Caterpillar Inc.||Liquid natural gas cryogenic tank leak detection system|
|US20140333444 *||7 May 2013||13 Nov 2014||Caterpillar Inc.||Liquid natural gas cryogenic tank leak detection system|
|U.S. Classification||429/411, 340/605, 73/40.50R|
|International Classification||G01M3/04, H01M8/04, G08B21/00|
|Cooperative Classification||H01M8/04201, H01M8/04776, H01M8/04186, H01M8/1011, H01M8/04686, H01M8/04753, Y02E60/523|
|European Classification||H01M8/04H6D2, H01M8/04H4M6, H01M8/04H6D8, H01M8/10C2, H01M8/04C6, H01M8/04C4|
|3 Aug 2007||AS||Assignment|
Owner name: IDATECH, LLC, OREGON
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:BELIVEAU, CLINT A.;ELLIOT, SCOTT C.;POPHAM, VERNON WADE;REEL/FRAME:019650/0239;SIGNING DATES FROM 20070516 TO 20070517
Owner name: IDATECH, LLC, OREGON
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:BELIVEAU, CLINT A.;ELLIOT, SCOTT C.;POPHAM, VERNON WADE;SIGNING DATES FROM 20070516 TO 20070517;REEL/FRAME:019650/0239
|9 Feb 2010||CC||Certificate of correction|
|23 Mar 2010||CC||Certificate of correction|
|27 Mar 2013||AS||Assignment|
Owner name: DCNS SA, FRANCE
Free format text: OPTION;ASSIGNOR:IDATECH, LLC;REEL/FRAME:030100/0642
Effective date: 20130313
|19 Jul 2013||REMI||Maintenance fee reminder mailed|
|22 Nov 2013||FPAY||Fee payment|
Year of fee payment: 4
|22 Nov 2013||SULP||Surcharge for late payment|